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From Total Resources, the Total Deliveries are subtracted. Total Deliveries (line 28) consists of
all retail sales, all full requirements wholesale sales within the system boundary, and all
deliveries to Golden Spread load points within the system boundary. The resulting value is the
Total Losses (line 30), which are the actual losses experienced during the 2013 Study Period.
Line 31 is SPS's total system loss percentage during the 2013 Study Period, which is derived by
dividing Total Losses (line 30) by Total Resources (line 22).
This value of Total Losses is the value that will be used to generate the loss factors by voltage
level.
The "Net Output to Lines by Segment" data (lines 41-53) are simply the sums of monthly values
for "Net Output to Lines" (line 38) for the months contained in each segment. The determination
of segments is discussed in Section 3.1 and the Net Output to Lines by Segment data are used in
determining transmission line losses in Section 4.3.
2.0 Generation Step-Up Transformer Losses
During the time since the last loss study, meters were installed or re-calibrated to measure the
power flow at the high-side of the step-up transformers. Losses attributable to these transformers
are included in station power and not part of this study.
3.0 System Load Analysis
To determine the transmission and autotransformer losses, it is necessary to perform powerflow
studies at different load levels. The loading levels must be determined before these studies can
be done. For the period under study, the system loads are obtained from the operations center.
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The load represented in these studies is a composite of SPS retail load, GSEC, and other
wholesale loads within the system boundary.
Any other sale or purchase of energy that either started in or was received into the SPS control
area, and including any through transactions from the east to west or west to east across the SPS
system between the eastern and western grids are included when the powerflow models are
developed to capture any transmission losses due to those transactions.
The individual loads at SPS's daily minimum and maximum load are summed to produce a daily
average load. Then the corresponding values for tie line flows are obtained and summed for the
same hour.
This produces a daily minimum and daily maximum load to be analyzed. The
results of this procedure are shown in Appendix D, Daily Maximum/Minimum Loads graph.
3.1 Segment Derivation
The daily maximum and minimum loads are still too detailed for the powerflow analysis, since
there are 365 values for each load. The next step is to produce a daily average load graph. This
graph is shown in Appendix D as the Average Value Analysis. The average load is graphed for
the study period. Then an average study value is fitted to the graph. The goal of this fit is to
minimize the sum of the errors between the average load values to be used in the study and the
actual daily average load.
Once this has been determined, the year can be broken into load
segments which will be modeled in the powerflow program by the values of average load
determined here.
The load segments will typically be January-May, June-August, and
September-December, but there are frequently more than 3 load segments when the study period
is not a calendar year. It is required that the segments correspond to monthly boundaries, since
additional data is also calculated besides the loads for the powerflow studies. For the 2013 Study
Period, the best fit to model the loads for the 12 months was a four segment model. The sum of
the errors in the 2013 Study Period is 0.18%. See App. D, System Load Data, line 8, col. AC.
The segment values used in this analysis were:
Segment 1:
July - August
4649 MW
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Segment 2:
September - February
3437 MW
Segment 3:
March - April
3572 MW
Segment 4:
May - June
4019 MW
The average loads per segment, number of days in each segment and other values used in the
analysis are shown on the Appendix D chart entitled "System Load Data."
3.2 Powerflow Loss Calculation
Once the segment loads have been determined, the powerflow analysis can be performed. The
average study value determined above is used for the load in the powerflow studies. There are
powerflow cases, representing each of the load segments under study. The generation patterns
are varied between the segments to better represent the mix of generators actually on-line at that
time of the year.
There is also a peak powerflow case prepared to analyze the system losses at the hour of the
system peak.
The powerflow program used is Power Technologies Inc.'s PSS/E program.
Once the
powerflows have been created, the losses are summarized for SPS's system. The loss values for
each transmission element and voltage class are tabulated for the peak hour case and for each
segment. The summary tabulations are contained in Appendix N. These losses represent the
loss for that element at that average segment load. These values are then used to determine the
transmission and transformer losses.
Excluded from the loss tabulation are transmission systems that are not owned by SPS, but reside
inside SPS's control area. These systems are Lea County Electric, Lubbock Power and Light,
Sharyland Utilities, and Tri-County Electric Cooperative.
4.0 Transmission Line Losses
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The losses for transmission lines consist of several parts. For demand loss at peak load, there is
corona and insulator loss. For energy loss, there is the corona and insulator loss and the energy
losses due to power flow through the lines. These losses are tabulated by transmission voltage
level in Appendix E.
4.1 Transmission Line Corona and Insulator Losses
Transmission systems have losses due to corona and insulator leakage. Corona loss occurs when
the voltage gradient near the conductor surface exceeds the breakdown strength of the
surrounding air. The Transmission Line Reference Book published by Electric Power Research
Institute contains information on determining the representative losses associated with corona
and insulator leakage. Using that reference, losses per mile for each transmission voltage level
were determined and entered in the "KW Loss/mile" column. Transmission line mileage was
taken from FERC Form 1 data. The demand loss due to corona and insulator loss (App. E,
"Demand Losses" column). is calculated by multiplying the kW loss per mile for a specific
voltage level times the miles of transmission operating at that voltage and then dividing that
product by 1,000 to yield a MW loss result. The energy loss is simply the demand loss times the
number of hours per year. For 345 kV transmission lines, for example, the corona and insulator
demand loss of 1.46 MW in App. E is the rounded value of this equation: (2.343 kW loss/mile x
623.00 miles) = 1,000. The annual energy loss (12,787 MWH) for these same elements is the
product of 1.459689 MW (the unrounded value from the previous equation) x 8,760 hours/year.
4.2 Transmission Line Demand Losses
The losses obtained for transmission lines are shown in Appendix E, labeled Transmission Line
Demand Loss. The peak demand losses were determined by tabulating the megawatt losses per
transmission line as shown in the 2013 Study Period peak powerflow study in Appendix N.
These losses are tabulated by voltage class.
4.3 Transmission Line Energy Losses
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The energy loss for the transmission lines at each voltage level is determined by using the losses
developed in the powerflows for each load segment. The segment loads are listed in Appendix E
along with the net output of power to the transmission system during the segment. This value
was determined in Appendix A and labeled "Net Output to Lines By Segment." The Net Output
to Lines is the amount of generated and purchased energy put onto the transmission system to
serve load. The determination of the energy losses for transmission lines of a specific voltage in
a specific segment is calculated using the following equations.
Segment Loss Factor =
Segment Loss for Transmission Element, MW
Segment Load, MW
(4.3.1)
Segment Losses = Seg Loss Factor x Net Output to Lines for Segment, MWH (4.3.2)
Thus, the powerflows provide a determination of the energy loss as a single value. Dividing by
the segment load produces a per MW loss factor which when multiplied by the Net Output to
Lines for that segment produces the energy loss for that element in that load segment. The
energy loss values for the year are simply the sum of the energy loss values for each element in
each load segment and appear on App. E a lines 37-43 under the column heading "Total Segment
Losses, MWH."
5.0 Autotransformer Demand Losses
SPS's transmission system autotransformers reduce voltage from one transmission level to a
lower transmission level.
The high side and low side autotransformer voltages are typically
written as "345/230," "230/115" and "115/69."
See, e.g., App. G. lines 2, 11 and 41. Each
autotransformer in SPS's transmission system is identified in Appendix G.
The load losses
related to autotransformers can be separated into demand and energy components.
The demand component was determined by two steps. The first step was to determine the
demand loss from each autotransformer from the summer peak powerflow study, summarized in
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Appendix N. This provided the loss due to loading at the peak time of the year. These losses are
stated for each of three types of autotransformers at lines 3, 5 and 7 of Appendix F.
The second component of the autotransformer demand loss was provided by summing the
individual transformer no-load losses for those operating at a particular voltage class from the
tabulation in Appendix G. This component represents the loss incurred by simply energizing the
transformer, as described below.
5.1 Autotransformer Energy Losses
The energy losses related to autotransformers can also be separated into two parts. The first part
is the energy loss associated with no-load operation.
This is the energy loss that is due to
energization of the transformer from the magnetizing currents. These values were determined by
taking the no-load loss, as tabulated in Appendix G, and multiplying by the number of hours in
the 2013 Study Period because these autotransformers are assumed to be energized throughout
the study period.
The energy losses related to loading were determined by the same methodology as for
transmission lines.
For each powerflow study, a tabulation of the autotransformer losses by
voltage level was done and these losses were also expressed as a percentage of the net load for
that powerflow study.
The autotransformer losses for each segment were determined by
multiplying the percentage by the net generation occurring during that segment. This produces
the average losses for each voltage level for each segment.
The data needed to make these
calculations and the results are shown in Appendix F. The equations used to obtain the energy
losses for the autotransformers are the same as Equations 4.3.1 and 4.3.2.
All losses discussed to this point are transmission level losses.
The losses discussed in the
following sections 6 through 10 are losses at the distribution level.
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6.0 Distribution Substation Transformer Losses
Distribution substation transformers are those transformers that reduce the transmission voltage,
e.g., 69 kV, to a distribution voltage, such as 33 kV, 22 kV or 12.5 W. The data for each
distribution substation transformer are in Appendix I.
Manufacturers' data were used to
determine losses. If manufacturers' data were not available for a specific transformer, data for a
similar transformer manufactured by another company were used.
Column 9 has a code for verification of data. The codes used in this field mean:
R - ratings were verified from manufacturer's data
L - loss values were verified from manufacturer's data
E - loss values are an estimate
There are many transformers on SPS's system that are either owned by a specific customer or
have metering or other arrangements to reflect the billing on the high side of the transformer, i.e.,
before losses are incurred.
These transformers are excluded from the loss calculations in
Appendix I, and excluded from App. I's list of transformers, because SPS does not incur the
losses associated with these transformers (the losses are borne by the customer leasing the
transformer). In some situations, only a portion of a transformer is leased, and thus, only a
portion of the losses associated with that transformer should be excluded. These transformers
are identified by the letter "E" in column 10 of App. I, and the percentage of losses to be
excluded is stated in column 15. The letter "I" in column 10 means that transformer is fully
included in the loss calculations.
6.1 Distribution Substation Transformer Demand Losses
The demand losses associated with these transformers have two components.
The first
component is the magnetizing current losses that are present anytime the transformer is
energized. The second component is the full load loss value for the transformer. Manufacturers'
test report data was used to determine the no-load loss and the loss when the distribution
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transformers were loaded to their nominal MVA ratings (App. I, Col. 4).
Loading of
transformers at their nominal MVA rating is referred to in App. I as "full load" but this label
does not mean that the transformers have no additional capacity. The maximum MVA loading
for each transformer is listed in App. I, Column 5. As evidenced by the differences between the
values in columns 4 and 5 of App. I, many transformers can handle loads in excess of their
nominal "full load." The no-load losses and nominal "full load" losses for each transformer are
tabulated in Appendix I, columns 6 and 7, and totaled for the entire system at the bottoms of
Columns 6, 7, and 8.
It was assumed for the purposes of this study that the distribution transformers were operating at
"full load" (their nominal MVA ratings) at the time of the system peak. This assumption was
reasonable, conservative, and necessary. The transmission and distribution system is designed to
handle the system's peak load and have additional capacity available in case peak load is greater
than forecasted.
And, of course, system load has grown since most of these transformers were
originally sized and installed.
Thus, at the time of system peak, it is likely that many
transformers operated somewhere between their nominal and maximum MVA ratings. Thus,
basing losses upon only the nominal MVA loading, as SPS has done, is conservative. Using this
assumption was necessary since manufacturers typically provide test data only for losses at the
nominal MVA rating.
6.2 Distribution Substation Transformer Energy Losses
The energy loss has two components. The first is the no-load loss, which occurs during every
hour of the Study Period. Referring to Appendix I, this value was calculated by multiplying the
no-load losses derived from manufacturers' test data, column 6, by the number of hours in the
Study Period, which results in the energy loss during the Study Period, as shown in column 12.
The full load loss required the determination of the load characteristic of the load being served
by a particular transformer. The load factor assigned to each transformer is shown in Appendix
I, column 11.
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The load factor for a study period is defined as:
Load Factor =
Total Study Period Energy
Max. Demand x Hours in Study Period
(6.2.1)
For the purpose of determining the study period energy losses, the following equation was used:
Losses = Full Load Loss x Hours in Period x Load Factor
(6.2.2)
The results of this calculation are shown in Appendix I, column 14.
The "Sum of demands adjusted for Primary Generation: is the estimated load at primary and
shown on line 290. The 54.139 MW adjustment shown on line 289 are the coincident wind and
solar primary generation at system peak hour and reduce the total load on the primary feeders.
Generation at primary may be used at the primary voltage level and never get transformed to the
transmission voltage level.
6.3 Calculation of Load at Each Feeder Voltage Level
The load at each feeder voltage level is calculated at lines 298-304 of Appendix I. The loading
on 33 kV feeders, for example, is calculated by determining the ratio of the nominal MVA of
transformers connected to 33 kV feeders (108.90 MVA on line 299) to the adjusted nominal
MVA of all distribution substation transformers (2,702.78 on line 299) and then multiplying that
ratio by total loading on all distribution feeders (line 290).
Thus, for 33 kV feeders, the
calculated loading is: (108.90/2702.78) x 2213.90 MW = 89.20 MW. This value appears at line
300 of Appendix I in the "33" column. From this value, the load on transformers with no feeders
(line 301) is subtracted to yield the load on 33 kV feeders, which appears on line 304. Line 302
presents data on total numbers of feeders at each voltage level and (line 303) the number of
feeders after excluding the portions of transformers that are shared with customers.
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7.0 Load Factor Derivation
The load factors used to calculate the study period energy losses reflected in Appendix I, column
13, provide representative load factors for substation loads. However, the load factors are not a
pure load factor, such as might be found for a rate class. Rather they represent the composite
mix of customer load which occurs on the power system.
The data used in Appendix H comes from rate analysis of each customer class on SPS's system
for the Study Period. Using this data, monthly demand peaks and monthly energy deliveries, a
composite load is developed which represents the desired substation class load.
With the
summed energy and demands, a load factor can be calculated. The load factor for distribution
connected load, Loss Level 4 through 6 is shown in Appendix H, line 78.
8.0 Distribution Primary Feeder Losses
The primary distribution network (Level 4 in the loss study) consists of the distribution lines
(feeders) that transport power from the distribution substation to the distribution line
transformers near each customer. The losses associated with these primary distribution feeders
are calculated on Appendix J. At the top of Appendix J, the distribution loads and energy are
summarized for the Study Period.
They are broken into loss levels and they represent the
demand and energy for each level of the distribution system. These values shown are derived
from Appendix H and they will be used throughout the distribution loss calculations.
Losses are calculated for 521.92 feeders operating at 6 nominal voltage levels (33 kV, 22 kV,
13.2 kV, 12.5 kV, 4.16 kV and 2.4 kV). There are 536 feeders connected to the transformers
(App. I, line 302), but some feeders are connected to transformers that are shared with
customers. Thus, the number of feeders at each voltage level has been reduced in proportion to
the nominal MVA of substation transformers at each voltage level leased by customers.
The
percentage of each transformer's capacity leased to a customer is shown in column 15 of
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Appendix I.
This process produces fractional feeders that are used to calculate primary
distribution feeder losses.
8.1 Distribution Primary Feeder Demand Losses
The load and number of feeders at each voltage level are derived from lines 304 and 303,
respectively, of Appendix I.
The Feeder Current, in amps, is:
Feeder Current =
FeederLoad
(AF3) x Feeder Voltage
The Feeder Loss, in watts, for a given voltage level is :
Feeder Loss= 3 x (Current)2 x Resistance x Avg. Length
(8.1.2)
The length of each feeder varies considerably as do the wire sizes (conductors) used in the
construction, which affects resistance. The distribution system database consists of 567 feeders
ranging in length from zero to 60.5 miles and many different wire sizes and materials. The
typical conductor size was determined by summing the feeder lengths by voltage by conductor
type and size and selecting the most common conductor based on length and conductor material
and size.
The results of this investigation appear in the "Typical Conductor" column on
Appendix J.
The average feeder length was determined by sorting the feeders by voltage and dividing the sum
of the lengths by the number of feeders in each voltage. A feeder was counted if the length was
greater than 0.05 miles.
There were 515 feeders that fit this criteria.
The results of this
investigation appear in the "Avg. Feeder Length, Miles" column on Appendix J.
The total loss for a given voltage level is obtained by multiplying the loss determined above by
the number of feeders in the given voltage level.
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8.2 Distribution Primary Energy Losses
These losses were calculated by multiplying the demand energy loss for the entire load served
via primary distribution line by the hours in the study year and by the loss factor for the entire
distribution load. The load factor is determined in Appendix J from the Total Primary Demand
and the Total Energy. The Loss Factor is determined from equation 2.2.2. Thus, the losses over
the year are determined by the following equation.
Loss = Demand Loss x 8760 hours x Loss Factor
(8.2.1)
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9.0 Distribution Line Transformer Losses
Appendix K contains the loss calculations for distribution line transformers, which corresponds
to loss level 5. The number of meters and transformers are actual counts derived from SPS's
records. The meters per transformer data is derived by dividing the adjusted meter count by the
number of transformers, e.g., 331,250 single phase meters/93,753 transformers equals 3.53322
meters/transformer.
In calculating losses, it is necessary to distinguish between single phase transformers, which
serve primarily residential customers, and three phase transformers, which serve primarily
commercial customers. The "Adjusted Meters" column on Appendix K performs this function
by assigning the single phase commercial meters to the "Residential" category, i.e., Residential
Adjusted Meters equals actual residential meters (293,839) plus the difference between all
commercial meters and three phase commercial meters (38,871).
It was assumed that one residential customer took service directly from each distribution line
transformer and that all other residential customers were served from secondary distribution
lines. Secondary lines are the lines that typically run from a pole top transformer to another pole
that has no transformer. From that second pole, a service line (a drop) runs to the customer's
premises. Losses on secondary lines and drops are addressed in Appendix L. For three phase
commercial customers, the number of transformers essentially equals the number of meters, and
thus, each such customer is assumed to be served directly from the transformer.
9.1 Distribution Line Transformer Demand Losses
Based on consultation with distribution system engineers, typical transformer sizes were chosen
as 25 KVA (residential) and 100 KVA (commercial). The transformer loss data at no load and
"full load" for each size are listed in Appendix K at lines 26 and 27. The average load per
customer is developed by taking the demand served and dividing by the number of customers.
Then the loss per transformer is developed by taking the load per customer and calculating the
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losses proportionally to the load served by the transformer and its full load rating. The total
demand loss is determined by multiplying the number of transformers by each no-load and full
load loss component. The no-load and loaded losses are shown at App. K, lines 35 and 37, and
totaled at lines 39 and 41.
9.2 Distribution Line Transformer Energy Losses
These losses were calculated by using the demand energy loss for the distribution line
transformers and multiplying by the loss factor of the load served through the distribution
transformers and by the number of hours in the Study Period. The load factor is determined from
data in Appendix K using the Total Secondary Dist. Transformer Demand and the Total
Secondary Dist. Transformer Energy. The Loss Factor is determined from equation 2.2.2. Thus,
the losses over the year are determined by the following equation.
Loss = Demand Loss x 8760 hours x Loss Factor
(9.2.1)
10.0 Distribution Secondary Losses
The distribution secondary losses are determined in Appendix L. To determine the secondary
losses, it was estimated that the secondary conductor was 1/0 MCM ACSR conductor and that
there was 60 feet of conductor serving each residential meter not served directly from the
transformer. The resistance of this secondary was 0.0127 ohms. The typical residential load and
current and commercial load and current were determined in Appendix K.
There is no
consideration of commercial load on secondary lines, as these customers are usually served
directly from transformers.
10.1 Distribution Secondary Demand Losses
There was assumed to be 2 meters per 60 foot of secondary line. The loss, in watts, on the
secondary was determined by the following equation:
Loss= (2x 12 x R)
(10.1.1)
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Multiplying by the number of meters (Appendix K) produces the total loss for the distribution
secondary.
10.2 Distribution Service Line Demand Losses
It was estimated that residential service line consisted of 65 feet of #2 Triplex and commercial
service line consisted of 30 feet of #1/0 Quadriplex service wire. The resistance for these service
lines are 0.02028 ohms and 0.00636 ohms, respectively. The current for each type of customer is
calculated and the losses are calculated by the following equations:
Loss = 2 x 12 x R, for residential customers and
(10.2.1)
Loss = 3 x 12 x R , for commercial customers.
(10.2.2)
The total loss for each group was determined by multiplying the loss per meter by the number of
meters, which are found on Appendix K.
10.3 Distribution Secondary and Service Lines Energy Losses
These losses were calculated by adding the demand loss of both the Secondary and Services and
multiplying by the number of hours in the test year and also multiplying by the loss factor of the
load that is served by Secondary and Services. The load factor is determined from data in
Appendix L using the Total Secondary Dist. Transformer Demand and Total Sec. Distribution
Lines demand and their associated energy. The Loss Factor is determined from equation 2.2.2.
Thus, the losses over the year are determined by the following equation.
Loss = Demand Loss x 8760 hours x Loss Factor
(10.3.1)
The results of this calculation are shown in Appendix L.
11.0 Summary of Transmission Loss Study
Appendix M contains the results of all of the calculations discussed previously. The power
system elements for which losses are determined are:
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Transmission Lines
Autotransformers
Distribution Substation Transformers
Distribution Primary Lines
Distribution Line Transformers
Distribution Secondary and Service Lines
Line 42 lists the total of the value obtained by the study, labeled as "Total Determined Losses".
Line 44, labeled "Losses," is the actual losses determined in Section 1.2 of this report.
The
difference between the results of this study and the actual losses is shown on line 43 as
"Undeterminable Losses". Typically, the results from a loss study will be within a few percent,
plus or minus, of the actual losses. For the 2013 Study Period, the Total Determined Losses are
over estimated by 0.83% of actual losses. It should be noted that nowhere in this study is the
actual loss value used to force the loss study to produce a final answer equal to the actual loss
value.
The results of this study are used to determine loss factors for rate classes. To do this, all actual
losses must be accounted for, and thus, the Undeterminable Losses (line 43) have to be allocated
to loss levels.
Each category of energy losses is allocated a portion of the Undeterminable
Losses equal to the ratio of that category's calculated losses to Total Determined Losses in
MWh. For example, the "Adjusted Energy MWh" value for Transmission Lines - 345 kV (line
14), which is 38,389 MWh, is determined by: 38,707 MWh (line 14 determined energy loss) x
(1,821,919 MWH Total Losses /1,836,997 MWH Total Determined Losses).
The values of factored energy loss, at the far right side of Appendix M, are used in the
development of the rate class loss factors.
12.0 Loss Factor Derivation
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Appendices 0 and P contain the derivation of the rate class loss factors from summary data
derived in various sections of the report. The rate class loss factors are determined for the loss
levels shown in Appendix 0 and P.
The method to determine the loss factors is based on starting with the total resource input to the
system at Generation Level, Level 1. This value is the starting point for the worksheet. Using
Appendix 0 as an example, from this value, the deliveries for that level and the losses for that
level are subtracted, leaving the `Net KWH into each Loss Level'. This calculation is done for
each loss level, with the result that all losses and deliveries have been subtracted from the Total
Resources, with a result of zero. This means that all deliveries and losses have been assigned to
a loss level and there is no error. Loss factors are calculated at each level as the subtraction
progresses to the right through the loss levels. The calculation is shown in the appendices along
with the loss factors by rate classification.
The process of calculating the Demand Loss Factor in Appendix 0 is the same as described for
the energy factor calculation. However, rather than redistributing any "Undeterminable Losses"
among the different loss levels, the "Total Determined Losses" from Appendix M is used.
Appendix Q contains the Demand and Energy Loss Factors by rate class in summarized form,
without their respective derivations. The composite loss factors are shown for rate classes in loss
levels 5 and 6.
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SCH 3 - Page 99 of 490
06758
Schedule 0-6.3
Page 26 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix B
Not used in this loss evaluation study
SCH 3 - Page 100 of 490
06759
Schedule 0-6.3
Page 27 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix C
Generator Step-up Transformer Energy Losses
Not used in this loss evaluation study
SCH 3 - Page 101 of 490
06760
Schedule 0-6.3
Page 28 of 55
Sponsor: Luth
Docket No. 45524
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06761
Schedule 0-6.3
Page 29 of 55
Sponsor: Luth
Docket No. 45524
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06762
Schedule 0-6.3
Page 30 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3 - Page 104 of 490
06763
Schedule 0-6.3
Page 31 of 55
Sponsor: Luth
Dnrket No. 45524
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SCH 3 - Page 105 of 490
06764
Schedule 0-6.3
Page 32 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3 - Page 106 of 490
06765
Schedule 0-6.3
Page 33 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix G
Autotransformer
No-Load Losses
Line
No.
Location
Voltage
Nominal
Rating
MVA
Max
Rating
MVA
No Load
Loss,
Watts
225
135
230/120
I AMARILLO SOUTH
23 7700005 39 6199989
115/69
2 ARTESIA TNT
23 7700005 39 6199989
115/69
3 ARTESIA INT
23 7700005 396199989
115/69
4 ATOKAINT
84
84
115/69
5 BAILEY CO
84
84
115/69
6 BAILEY CO
84
45
115/69
7 BLACKHAWK
84
45
115/69
8 BLACKHAWK
150
90
230/131
9 BORDEN CO
84
45
120/69
10 BOWERS
150
90
230/115
11 BUSHLAND
150
90
230/115
12 CARLISLE
23 7700005 39 5999985
115/69
13 CARLISLE
396
23 77
115/69
14 CARLSBAD INT E
395
23 77
115/69
15 CARLSBAD INT W
75
45
115/69
16 CASTRO N
75
45
115169
CASTRO
S
17
150
90
230/115
18 CHAVES CO INT E
225
135
230/120
19 CHAVES CO INT W
396
23 77
115/69
20 CHAVES INT
395999985
23
7700005
115/69
COCHRAN
21
23 7700005 395999985
115/69
22 COCHRAN
75
45
115/69
23 COULTER
84
45
120/69
24 COX
23
7700005
395999985
115/69
25 CROSBY 4T1
23 7700005 395999985
115/69
26 CROSBY #T2
150
90
230/115
27 CUNNINGHAM
23 7700005 396199989
115/69
28 CURRY
75
45
115/69
29 CURRY
396
23 77
115/69
30 DALHART
23 7700005 39 5999985
115/69
31 DALLAM
150
90
230/115
32 DEAF SMITH #1
150
90
230/115
33 DEAF SMITH #2
84
50
34 DENVER CITY INTCHG 115/69
84
50
35 DENVER CITY INTCHG 115/69
84
50
115/69
36 DOSS INTCHG
225
135
230/120
37 EASTPLANT
84
50
115/69
38 EAST PLANT
84
50
115/69
39 EASTPLANT
150
90
230/115
40 EDDY CO INT (Ti)
560
300
345/230
41 EDDY CO INT
250
150
230/115
42 EDDY CO INT (T2)
23 7700005 395999985
115/69
43 EAGLE CREEK
23 7700005 39 5999985
115/69
44 FLOYD CO
84
45
120/69
45 FLOYD CO INTCHG
44
23 7700005
115/69
46 GAINES 41
396
23 7700005
115/69
47 GAINES #2
39 6
23 77
115/69
48 GRAHAM CO
100
60
230/115
49 GRAPEVINE INTG
100
60
230/115
50 GRASSLAND
75
45
115/69
51 GRAY CO
396
23 77
115/69
52 HALE CO
396
23
77
115/69
53 HALE CO
39 617
23 77
115/69
54 HAPPY INTG E
39617
23 77
115/69
55 HAPPY INTG W
23 7700005 396199989
115/66
56 HEREFORD
396199989
23
7700005
115/69
57 HEREFORD
560
336
345/230
58 HITCHLAND
250
150
230/115
59 HITCHLAND
84
50
115/69
60 HOCKLEY
84
50
115/69
61 HOCKLEY
75
45
115/69
62 HOWARD
75
45
115/69
63 H1TfCHINSON
150
90
230/115
64 HUTCHINSON
150
90
230/115
65 HUTCHINSON
75
45
115/69
66 KINGSMILL (Ti)
84
50
115/69
67 KINGSMILL (T2)
84
50
115/69
68 KRESSINTCHG
225
135
230/120
69 LAMB CO
84
45
120/69
70 LAMB CO
84
45
120/69
71 LAMB CO
75
45
115/69
72 LAMBTON INTG
150
90
230/115
73 LEA CO INTG
84
50
115/69
74 LEGACY
150
90
230/115
75 LUBBOCK EAST
55,440
15,268
17,600
21,060
17,540
18,460
14,335
14,249
30,906
69,440
86,001
57,968
18,380
16,900
22,450
14,901
14,917
60,700
61,380
18,700
17,600
16,150
25,659
17.400
17,300
21,930
84,128
20,110
26,000
20,200
17,840
59,030
35,300
18,860
18,660
17,000
71,492
18,200
17,340
55,794
75,788
37,500
18,205
20,640
22,270
10,900
22,000
16,670
47,450
51.300
24,519
16,720
17,328
19,700
19,700
21,000
23,340
86,954
62,938
25,100
23,700
33,190
28,199
84,172
90,549
33,190
18,560
24,100
69,698
23,000
23,000
14,230
83,572
25,140
70,680
Ener Losses, MWH
345kV 230kV 115kV
663 90
-
485 65
270 74
75337
507 80
531 73
537 69
736 96
517 10
309 23
62627
488 76
328.50
-
-
415 66
449 39
551.34
-
-
737 35
793 21
610 55
732 09
619 16
133 75
154 18
18449
153 65
161 71
12557
124 82
608 29
161 01
148 04
196 66
130 53
130 67
163 81
154 18
14147
224 77
15242
151 55
192 11
176 16
227 76
17695
156 28
165.21
163 46
148 92
159 43
15190
159 48
180 81
195 09
95 48
19272
146 03
214 79
14647
151 79
172 57
172 57
183 96
204 46
761 72
21988
207 61
29074
24702
290 74
162 59
21112
201 48
201 48
124 65
220.23
-
Demand Losses, KW
345kV 230kV 115kV
-
55 44
30 91
8600
57 97
1527
1760
2106
1754
1846
1434
1425
6944
-
60 70
6138
84 13
-
18 38
1690
2245
14 90
14 92
18 70
17 60
16 15
25 66
1740
17 30
21 93
2011
2600
20.20
17 84
18 86
.
1966
17 00
18 20
1734
-
75 79
-
59 03
35.30
71.49
55 79
3750
-
-
4745
5130
-
86 95
-
6294
84 17
9055
-
-
69 70
-
2820
33 19
18.56
2410
23 00
23 00
1423
-
83 57
70 68
2514
-
-
1821
2064
22 27
10 90
.
2200
16 67
2452
16 72
1733
1970
1970
21 00
2334
2510
23 70
SCH 3 - Page 107 of 490
06766
Schedule 0-6.3
Page 34 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix G
Autotransformer
No-Load Losses
Location
Line
No.
76 LUBBOCK-EAST (N)
77 LUBBOCK-EAST (S)
78 LUBBOCK-SOUTH
79 LUBBOCK-SOUTH
80 LYNN CO
81 LYNN CO #2
82 MIDLAND CO
83 MOORE CO
84 MUSTANG
85 NE HEREFORD
86 NICHOLS-N
87 NICHOLS-S
88 NORTHWEST INTCHG
89 OASIS INTG
90 OCHILTREE
91 PCA #2 INT
92 PERRYTON INTG
93 PECOS
94 PLANTX
95 PORTALES
96 PORTALES
97 POTASH JCT
98 POTASH JCT
99 POTASH JCT
100 POTTER CO
101 POTTER CO
102 PRINGLE INTG
103 RANDALL CO (Tl)
104 RANDALL CO (1'2)
105 RIVERVIEW
106 ROOSEVELT
107 ROSWELL INT (TI)
108 ROSWELL INT (T2)
109 SEAGRAVES
110 SEMINOLE E
111 SEVEN RIVERS
112 SEVEN RIVERS
113 SEVEN RIVERS
114 SOUTH GEORGIA
115 SPEARMAN
116 SULPHUR SPNG
117 SULPHUR SPNG
118 SUNDOWN
119 SWISHER
120 TERRY CO E
121 TERRY CO W
122 TOLK
123 TUCO N
124 TUCO
125 TUCO
126 TUCO
127 TUCO
128 TUCO-South (T2)
129 TUCO SVC
130 WOLFFORTH
131 WHEELER
132 YOAKUM CO
133 YOAKUM CO
Voltage
115/69
115/69
115/69
230/115
115/69
115/69
230/131
230/115
230/115
120/69
230/115
230/115
120/69
230/115
230/115
115/69
115/66
230/115
230/120
115/69
115/69
230/115
115/69
115/69
345/230
230/115
230/120
230/115
230/115
115/69
230/115
115/69
115/69
120/69
230/115
115/69
115/69
230/115
115/69
115/69
120/69
120/69
230/118
230/115
115/69
115/69
345/230
120/69
230/115
230/120
120/69
345/230
345/230
230/13
230/115
230/115
230/115
230/115
Maa
Rating
MVA
Ener Losses, MWH
345 kV 230kV 115kV
230 65
22163
176 95
527 63
164 07
88 48
270 74
590 16
611 89
131 73
55451
51421
126 06
46446
453 77
15698
17345
44175
628.28
130 47
12793
634 05
221 80
222 15
49722
577 98
687 07
872 67
332 00
216 99
45790
164 16
15242
123 54
55451
135 96
135 96
51001
180 47
341
11
55 01
77 96
530 89
49932
214 62
211 12
679 71
130 96
476 85
584 64
131 22
51447
663 82
34243
70173
548 65
613 11
611 45
-
Total Ener Losses, MW
345kV 230kV 115kV
134
135
136
NoLoad
Loss,
Wafts
84 26,330
84 25,300
20,200
395999985
60,232
225
18,730
395999985
10,100
45
150 30,906
67,370
250
150 69,850
84
15,038
63,300
150
150 58,700
14,390
84
53,021
225
168 51,800
17.920
39 6199989
19,800
18 75
150 50,428
71,721
225
14,894
84
14,604
84
150 72,380
395 25,320
25,360
395
56,760
560
250 65,980
78,433
225
99,620
225
250 37,900
24,770
39 5
52,272
225
18,740
39 6199989
17,400
39 6199989
14,103
75
150 63,300
15,520
3962
39 62
15,520
150 58,220
75 20,602
38,940
25
6,280
448
8,900
44 8
60,604
166.667
57,000
150
84 24,500
84 24,100
77,592
560
14,950
84
54,435
252
66,740
250
14,980
84
58,730
560
75,779
560
150 39,090
150 80,106
62,631
69,990
150
90
150 69,800
90
Nominal
Rating
MVA
50
50
23 7700005
135
23 7999992
27
90
150
90
45
90
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45
135
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23 7700005
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23 7700005
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23 77
23 77
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18 75
24
24
100
90
50
50
300
45
135
150
45
300
336
90
90
Hours in Period
8760
3,019
25,595
14,919
Demand Losses, KW
345kV 230kV 115 kV
2633
2530
.
2020
6023
18 73
10 10
30 91
67 37
69 85
15.04
6330
58 70
1439
53 02
51 80
17 92
1980
.
5043
7172
14 89
1460
72 38
25.32
2536
56 76
65 98
78.43
99 62
37 90
24 77
77 59
-
5227
6330
-
18 74
1740
14 10
1552
15 52
58.22
60 60
57 00
-
.
2060
38 94
628
8 90
24 50
24 10
14 95
5873
75 78
-
5444
6674
3909
8011
62 63
69 99
69 80
14 98
-
Total Demand L osses, KW
345kV 230kV 115kV
432
2,922
1,583
SCH 3 - Page 108 of 490
06767
Schedule 0-6.3
Page 35 of 55
Sponsor: Luth
Docket No. 45524
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Schedule 0-6.3
Page 36 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3- Page 110 of 490
06769
Schedule 0-6.3
Page 37 of 55
Sponsor: Luth
Docket No. 45524
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06770
Schedule 0-6.3
Page 38 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3- Page 112 of 490
06771
Schedule 0-6.3
Page 39 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3- Page 113 of 490
06772
Schedule 0-6.3
Page 40 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3- Page 114 of 490
06773
Schedule 0-6.3
Page 41 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix I
Distribution Substation
-
Line
No.
--- - -
1
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
34TH STREET
ADAIR
AIKEN RURAL
ALLMON
ALLRED
AM-FRAC
AMHERST
ARROWHEAD
ARTESIA COUNTRY CLUB
ARTESIA S RURAL
ARTESIA TOWN
ARTESIA WEST 13th St
BAILEY PUMP
BAINER
BARWISE
BENNETT
BOARDMAN
BOOKER 35 KV
BOOKER 4 16 KV
BOWERS
BRASHER
BRISCOE
BROWNFIELD SWITCH
STATION
BUCKEYE
BUFFALO
BURNETT
BUSH
BYRD
CAMEX
CAMPBELL S'I'REET
CANADIAN
CANYON EAST
CANYON WEST
CAPITAN
CARLSBAD WATER
CARSON CO
CEDAR LAKE EAST
CENTRE ST
CHALA
CHANNING
CHERRY
CLIFFSIDE
COBLE
CONWAY
COOPER RANCH
CORTEZ
COTTONWOOD91
COULTER
COUNTY LINE
CRMWA41
CRMWA #2
CRMWA#3
CRMWA#4
CRMWA 21 (Adobe Creek) 4
CRMWA 21 (Adobe Creek) 13
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
CRMWA 22
CRMWA 23
CROUSE HINDS
CURRY CO
DALHART 2.4 KV
DALHART 12.5 KV
DALHART 35 KV
DAMRON
DAWN
DEXTER 34 5 KV
DEXTER 4 16 KV
DIEKEMPER
DIMMITT E
DIMMITT S
DOLLARHIDE
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
Ratin gs
Voltage
Max
Nominal
Low
High
MVA
MVA
Side,kV I Side,kV I
5
4
3
2
No Load Full Load
Losses
Losses
WATTS WATTS
7
6
Low
Side
Class
8
No Load Full Load Number of Percent
Transf.
r
Losses
Losses
Excluded
MWH
Circuits
MWH
14
15
12
13
Verify
Flag
R,L,E
9
Exclude
Flag
10
Primary
Load
Factor
11
1
I
1
1
E
1
I
1
1
1
1
I
I
1
I
I
E
1
1
1
1
1
I
0.5774972
057750
057750
0 57750
0 57750
057750
057750
057750
057750
057750
057750
0 57750
0 57750
0 57750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
166 48
110 14
40 37
95 44
0 00
49 73
68 68
10906
105 12
75.89
9221
85 85
9636
9221
67 98
103 11
0 00
41 11
6920
173 45
118 26
49 91
11747
32689
13100
7052
217 56
106 77
12442
144 89
281 12
20236
23636
164 34
28227
177 06
164 34
13942
282 18
190 65
117 97
123 94
285 90
291 90
76 54
158 65
4
1
1
1
2
0
2
2
2
2
3
2
1
1
2
3
2
1
3
3
3
2
1
1
1
1
1
1
1
1
I
I
I
1
1
1
I
1
1
1
I
1
E
I
1
I
1
1
E
1
1
I
1
I
1
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0.57750
057750
0 57750
057730
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
13823
40,25
7104
217 95
9287
113 88
15936
134 47
11125
116 86
92 94
60 55
14600
3504
180 11
42968
109 82
16161
111 06
0 00
191 32
15431
9224
2766
219 00
0 00
17952
142 39
12685
138.28
87 60
201 48
28064
112 79
23190
307 08
26759
151 77
332.50
280 72
294 93
257 80
289 72
105 78
28548
126 47
21931
45570
26948
34252
226 12
158 60
244 80
285.56
13801
49.30
37942
113 58
25450
18285
18090
181.23
161 88
40471
3
2
2
3
0
0
2
4
2
3
3
2
2
1
2
1
3
2
0
2
2
2
0
2
3
1
0
0
0
0
0
1
1
1
I
1
1
1
1
1
I
1
1
I
1
I
1
0 57750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0 57750
057750
057750
057750
69.20
210 77
171 70
161 75
104 77
138 89
154 09
151 11
6894
61 73
69 16
18 44
192 54
80 74
9724
123 94
338 24
319 22
26423
19451
255.49
214 88
282 54
11721
16227
123 25
32 87
349 92
141 04
23676
0
0
0
4
4
2
2
1
2
1
2
1
2
2
3
115
688
67
67
115
115
67
115
67
69
66
67
67
66
68 8
115
69
66
69
67
115
66
67
13 2
13 09
12.5
125
125
24
24
132
125
132
4 16
4 16
12.5
4 16
13 09
132
13.2
345
42
13 8
132
22
229
224
10
25
75
12
56
3 75
15
75
11.2
5
75
5
5
3 75
168
12
6
3 75
75
15
3
5
373
14
25
9.38
20
7
4687
25
938
14
5
11.26
56
5
4,2
28
20
84
3 75
10
25
3 92
5
19,005
12,573
4,608
10,895
19,630
5,677
7,840
12,450
12,000
8,663
10,526
9,800
11,000
10,526
7,760
11,770
9,410
4,693
7,900
19,800
13,500
5,697
13,410
64,617
25,896
13,940
43,006
57,040
24,595
28,640
55,570
40,000
46,721
32,485
55,797
35,000
32,485
27,560
55,780
45,960
23,320
24,500
56,515
57,700
15,131
31,360
13.2
125
12 5
12 5
125
24
24
13,2
125
132
4 16
4 16
12 5
4.16
12 5
125
12.5
33
4 16
132
132
22
22
RL
RE
115
69
69
115
115
67
115
67
115
115
69
67
115
66
67
115
115
115
688
67
115
115
115
66
115
69
115
115
115
115
67
67
12 5
13 2
132
13 8
42
24
125
24
132
132
13.2
125
138
125
13 8
138
345
13 2
436
125
13 8
13.2
42
125
13 8
1247
416
4 16
416
4 16
42
13 2
10
5
112
15
135
5
15
10
15
15
15
3 75
10
2
12
25
168
15
75
10
12
12
5
15
15
18 75
75
5
5
5
75
10
125
6.25
14
25
224
7
25
10
25
25
25
3 75
125
2
224
25
28
25
105
11
20
224
625
1.88
25
25
937
6 25
625
625
84
14
15,780
095
8,110
24,880
10,602
13,000
18,192
15,350
12,700
13,340
10,610
6,912
16,667
4,000
20,560
49,050
12,537
18,449
12,678
16,500
21,840
17,615
10,530
3,158
25,000
36,600
20,493
16,255
14,481
15,785
10,000
23,000
55,475
22,296
45,840
60,701
52,896
30,000
65,727
55,490
58,300
50,960
57,270
20,909
56,431
25,000
43,351
90,080
53,269
67,706
44,698
55,000
48,390
56,447
27,280
9,745
75,000
89,810
50,307
36,145
35,758
35,824
32,000
80,000
12 5
13 2
13 2
13 2
4 16
24
125
24
13.2
13.2
13.2
12 5
132
125
132
132
33
13.2
4 16
125
13.2
125
416
125
132
125
416
416
416
416
4 16
132
RL
RL
RL
RL
I UL
69
67
115
67
67
67
67
69
115
69
66
66
67
67
115
42
13 8
138
24
24
125
345
132
132
345
42
42
13.8
125
132
3 75
15
12
12
3 75
12
75
75
7.5
56
3 75
1.5
15
10
12
4 687
28
20
20
4 68
224
75
10
9375
7
3 75
1.5
25
12 5
224
7,900
24,060
19,600
18,465
11,960
15,855
17,590
17,250
7,870
7,047
7,894
2,105
21,980
9,216
11,100
24,500
66,861
63,100
52,230
38,450
50,503
42,475
55,850
23,170
32,076
24,364
6,497
69,170
27,879
46,800
4 16
13.2
13.2
22
24
12.5
33
132
13.2
33
4 16
4 16
12 5
12 5
125
RE
RL
RE
RL
RL
RL
RL
RL
RE
RL
RE
RL
RE
RE
RL
RL
RL
RE
RE
R,L
RL
RE
RL
RL
RL
RL
RL
RL
RL
RE
RL
RE
RE
RE
RL
RL
RL
RE
RL
RE
RL
RE
RL
RL
RL
RL
RL
RL
RE
RE
RL
RL
RE
RL
RL
RL
RL
RL
RE
RE
RL
RE
RE
63
18
43
75
SCH 3- Page 115 of 490
06774
Schedule 0-6.3
Page 42 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix I
Distribution Substation
Transformer Loss
Line
Na.
1
71 DOSS 132 KV
72 DOSS 22 KV
73 DRINKARD
74 DUMAS 19TH 35 KV
75 DUMAS 19TH 12.5 KV
76 DUVAL #3
77 EAST CLOVIS
78 EAST DENVER CITY
79 EAST LEVELLAND
80 EAST PLAINVIEW
81 EASTSANGER
82 EAST PLANT
83 ELWOOD
84 ESTACADO #1
85 ESTACADO #2
86 ETTER RURAL E
87 ETTER RURAL W
88 EUNICE
89 EXELL
90 FAIN
91 FARMERS
92 FARWELL
93 FIESTA
94 FLANNAGAN
95 FRIONA RURAL
96 FRITCH
97 GARZA N
98 GARZA S
99 GOODPASTURE
100 HALE CENTER
101 HAPPY CITY
102 HART INDUSTRIAL
103 HASTINGS
104 HENDRICKS
105 HEREFORD
106 HERRING
107 HIGHLAND PARK
108 HILLSIDE
109 HOBGOOD
110 HOPI
I I I HOWARD
112 IMC 43 Strata
113 IMC #4
114 INDUSTRIAL
115 IRICK
116 JAL
117 JAYBEE
118 KINGSMILL
119 KINNEY
120 KITE
121 KRESS RURAL
122 LARIAT
123 LAKE MEREDITH
124 LAWRENCE PK E#1
125 LAWRENCE PK W#2
126 LEA NATIONAL
127 LEA ROAD
128 LEHMAN
129 LEVELLAND CITY
130 LEVELLAND (EAST XFMR)
131 LITTLEFIELD CITY
132 LITTLEFIELD SOUTH
133 LIVINGSTON RIDGE
134 LOCKNEY RURAL
135 LOCKNEY RURAL 23
136 LYNN
137 LYONS
138 MALJAMAR
139 MALJAMAR 42
140 MALLET
141 MANHATTAN
142 MARKET STREET
Volta ge
High
Low
Side, kV
Sole, kV
3
2
69
67
115
115
115
67
118
67
69
68 8
115
115
67
115
115
115
115
115
115
115
115
67
115
69
115
115
72
72
69
67
66
67
67
66
67
115
115
118
69
69
118
69
69
67
66
115
69
69
69
67
69
67
118
67
67
115
115
115
69
66
67
67
69
69
69
69
67
115
115
67
115
66
132
249
13.2
345
12 5
42
13 2
125
13,2
13 09
125
132
125
132
132
345
345
132
125
125
13.2
24
13.2
13.2
229
132
25
25
12 5
12.5
125
125
132
22
13 8
345
13 8
132
42
13.2
132
125
13.2
13 8
125
13 8
125
132
24
13 2
125
125
132
13 8
138
132
125
125
13.2
2.4
42
125
13.2
125
22 86
229
13 8
125
42
13 8
13 8
125
Ratin gs
Nominal
Max
MVA
MVA
5
4
168
12
12
12
12
5
168
10
12
15
12
15
10
15
15
12
15
15
10
75
15
25
15
11.2
12
75
112
11.2
2
5
6
5
15
10
12
12
25
168
0.23
16 8
112
5
5
12
6
12
25
168
1
12
6
75
112
15
15
112
10
12
12
1 5
5
75
112
2.5
10
10
12
10
7
5
15
10
28
20
22 4
20
20
7
28
12 5
22.4
16 8
20
28
125
28
28
20
25
25
12 5
9375
25
2.5
28
14
20
9 38
14
14
2
5
7
625
25
13 33
20
20
416
28
023
28
14
6,25
5
20
7,26
20
3 125
28
15
20
6
9 375
14
25
25
14
125
20
224
15
625
9 375
14
25
10
10
20
125
124
5
25
10
No Load Full Load
Losses
Losses
WATTS WATTS
7
6
9,851
18,330
11,190
20,700
19,400
10,526
8,768
16,500
9,400
19,370
19,859
11,415
16.500
11,680
15,000
23,520
15,250
11,750
29,500
11,480
18,239
6,334
15,523
10,800
21,350
13,825
6,497
9,304
6,300
10,000
11,100
12,425
27,190
16,500
20,000
25,140
30,680
8,807
1,096
9,927
7,531
12,000
7,789
19,700
11,450
18,800
4,608
16,300
3,800
17,800
10,515
10,895
8,004
23,899
24,200
7,806
17,615
19,400
9,800
3,800
10,000
10,000
6,396
4,608
12,004
12,233
21,550
17,450
6,316
10,641
24,640
23,320
71,031
62,470
38,840
51,675
63,400
32,485
67,351
55,000
42,300
71,767
64,143
59,261
55,000
52,670
55,700
49,700
64,030
52,460
65.000
45.380
65,335
19,792
65,978
37,984
49200
41,819
45,517
47,534
18,000
35,000
36,880
31,575
77,050
50,000
45,000
51,450
101,010
67,624
3,150
70,540
41,570
48,000
20,101
57,300
36,845
63,000
13,940
67,300
11,875
55,630
10,922
43,006
40,923
60,360
71,126
43,297
56,447
63,000
49,600
11,875
30,000
35,000
44,866
13,940
35,123
37,682
52,560
58,016
29,319
39,077
63,513
58,600
Low
Side
Class
8
125
22
13.2
33
12.5
4 16
125
12 5
12 5
12 5
125
132
12 5
132
132
33
33
125
125
125
13.2
24
125
12 5
22
132
22
22
12 5
12 5
125
125
13 2
22
13 2
33
132
132
4 16
12.5
132
12 5
13.2
13 2
125
12,5
125
132
24
13.2
125
125
132
13 2
132
13,2
125
125
125
24
4 16
125
12 5
125
22
22
13 2
125
416
125
132
125
Verify
Flag
R,L,E
9
Exclude
Flag
RL
I
1
I
I
I
I
I
I
1
1
1
1
1
1
1
E
E
1
1
1
1
1
1
E
1
1
1
1
1
1
1
I
I
1
I
I
E
I
1
1
1
I
I
1
1
1
1
1
1
I
I
I
I
1
1
1
E
1
1
1
1
1
1
1
I
1
1
E
I
1
1
1
RL
RL
RL
RL
RL
RL
RE
RE
RL
RL
JUL
RE
JUL
R,L
RL
RL
RL
RE
RL
RL
R,E
RL
RL
RL
RE
RL
RL
RE
RE
RL
R,L
RL
RL
RE
R,L
RE
RL
R,E
RL
RL
RL
RL
RL
RL
RL
RE
JUL
RE
RL
RL
RE
RL
RL
RL
JUL
RL
RL
RL
RE
RE
RE
RL
RE
R,L
JUL
JUL
RL
RL
RL
RL
RL
10
Primary
Load
Factor
11
057750
057750
0,57750
057750
057750
0 57750
057750
0 57750
0 57750
0 57750
057750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
0 57750
0 57750
057750
057750
057750
057750
057750
0 57750
057750
057750
057750
057750
057750
0 57750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0 57750
057750
0 57750
057750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0 57750
0 57750
0 57750
0 57750
057750
057750
057750
057750
057750
No Load Full Load Number of Percent
Transf.
Losses
Feeder
Losses
MWH
MWH
Circuits
Excluded
12
13
14
15
8629
16057
98 02
181.33
169 94
9221
76 81
144 54
8234
169 68
17396
100 00
144 54
102 32
13140
0 00
0 00
102 93
258 42
100 56
159 77
55 48
135 98
0 00
187 03
121 10
5691
81.50
55 19
87 60
9724
108 84
238 18
14454
175 20
22023
000
77 15
9 60
86 96
65 97
105 12
68.23
172 57
100 30
16469
4037
142 79
33.29
155 93
92 11
95.44
70 12
209 36
211 99
68 38
0 00
169 94
85 85
33.29
87 60
8760
56 03
4037
105 16
107 16
188 78
0 00
55 33
93 22
215 85
20428
35934
31603
19649
26142
320 73
164 34
340 72
27824
213 99
363 06
32449
299 79
278 24
266 45
281 78
16846
21703
26539
328 83
22957
33052
100 12
333 77
103 76
248 90
21156
23026
24047
91 06
177 06
18657
159 73
389 79
252 94
227 65
26028
260 61
34210
15 94
356 85
21030
242 83
101 69
289 87
18639
31871
70.52
340 46
6007
281.43
55 25
217 56
20702
305 35
359 82
219 03
91 38
318 71
250 92
60 07
151 77
177 06
22697
70 52
177 68
190 63
265 89
58 70
14832
19769
321 30
29645
3
2
3
2
3
1
3
3
2
3
2
4
1
3
3
2
0
4
2
1
3
2
3
1
2
2
1
1
1
2
2
2
4
3
2
2
2
3
1
3
2
1
0
3
2
3
1
5
0
3
3
1
3
3
3
2
2
2
2
2
4
2
3
2
2
3
2
0
0
2
3
1
33
33
46
49
68
80
-
SCH 3- Page 116 of 490
06775
Schedule 0-6.3
Page 43 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix I
Distribution Substation
Line
No.
1
143 McCLELLAN (GROOM PUMP
STATION)
144 MCCULLOGH
145 MCLEAN RURAL
146 MID-AM #2
147 MID AM #3 -m Swisher area
148 MIDDLETON
149 MILLEN
150 MISS CHEM #2
151 MONROE
152 MONUMENT
153 MOORE CO
154 MORTON
155 MOSS
156 MULESHOE CITY
157 MULESHOE EAST
158 MULESHOE VALLEY
159 MULESHOE WATERIELD @
Bailey Co
160 N CLOVIS
161 N E HOBBS
162 N HOBBS #1
163 N HOBBS #2
164 N PLAINVIEW
165 NAVAJO MALAGA
166 NM POTASH
167 NORRIS ST
168 NORTH CANAL
169 OCHOA
170 OCOTILLO
171 OLTON
172 OSAGE
173 OZARK MAHONING 62
174 PACIFIC
175 PALO DURO
176 PARMERCO
177 PCA #2
178 PEARL
179 PERIMETER
180 PERRYTON N
181 PERRYTON S
182 PHILLIP PUMP
183 PHILLIPS PUMP 2
184 PIERCE
185 PLAINVIEW CITY E
Transformer
186 PLAINVIEW CITY W
Transformer
187 PLANT X RURAL
188 PORTALES # 1
189 PORTALES 42 A
190 PORTALES #2 B
191 PORTALES SOUTH
192 PORTALES WATER FIELD
193 POST CITY
194 POTASH JUNCTION
195 PRENTICE W
196 PRICE
197 PUCKETT WEST
198 PULLMAN
199 RIAC EAST
200 RIAC WEST
201 RILEY
202 RIVERVIEW
203 ROBERTS CO
204 ROSWELL CITY N
205 ROSWELL CITY S
206 ROXANA
207 RUSSELL SUB E
TRANSFORMER
208 RUSSELL SUB W
TRANSFORMER
209 S FLOYDADA
No Load Full Load
Losses
Losses
WATTS WATTS
7
6
Ratin s
Max
Nominal
MVA
MVA
4
5
Voltage
High
Low
Side,kV
Side,kV
3
2
Low
Side
Class
8
Verify
Flag
R,L,E
9
Exclude
Flag
10
Primary
Load
Factor
11
Feeder of Percent
No Load Full Load Number
Transf.
Losses
Losses
Excluded
Circuits
MWH
MWH
15
14
12
13
115
132
5
5
9,216
27,879
132
RE
I
0 57750
80 74
141 04
1
67
115
67
67
67
115
67
66
118
115
67
67
67
67
69
66
132
132
24
24
125
125
12.5
22
13 2
132
24
24 9
24
24
12
125
15
75
3 75
5
10
12
3 75
10
16 8
15
5
10
3 75
3 75
5
15
25
9.375
3 75
56
125
20
4.69
133
28
28
6,25
10
3 75
469
6 25
15
23,044
17,700
8,800
14,150
14,400
19,889
7,851
20,680
10,781
12,650
10.526
17,985
9,501
9,501
7,440
2,765
65,351
58,000
23,950
42,000
54,818
63,525
27,329
47,900
65,108
52,720
32,485
47,480
29,687
29,687
21,250
8,364
132
13,2
24
24
125
12.5
125
22
125
132
2.4
22
24
24
125
125
RL
RL
RL
RE
RL
RL
RE
RE
RL
RL
1
E
I
I
1
I
1
1
1
1
I
I
I
1
I
1
057750
057750
0 57750
0 57750
057750
057750
0 57750
057750
0.57750
057750
057750
057750
0 57750
057750
057750
057750
201 87
000
77 09
123 95
126 14
174.23
68 77
181 16
9444
110 81
9221
157 55
83 23
83,23
65 17
2422
330 60
12617
121 16
21247
27732
321.37
138 25
242 32
32937
26670
16434
240 20
150 18
150 18
107 50
4231
3
2
0
0
2
3
0
1
3
3
2
2
2
2
1
1
118
115
115
115
67
66
69
115
115
118
118
67
118
67
115
115
115
67
115
118
115
115
69
69
115
65
132
132
125
12 5
12.5
4 16
13.8
132
132
132
132
125
13.2
24
125
132
22
13 2
125
132
125
125
24
24
13 8
24
168
15
12
12
10
3
75
12
15
168
168
75
16 8
5
12
75
75
16
5
168
75
75
25
25
15
75
28
28
20
20
10
3
105
20
25
28
28
75
28
56
20
105
75
224
625
28
11 72
105
28
28
25
75
11,544
11,232
21,320
20,830
16,500
6,316
16,680
13,396
15,291
10,000
9,851
13,825
11,789
9,501
19,300
8,520
17,800
13,825
9,216
10,330
9,800
15,500
5,109
4,837
23,053
9,501
61,309
59,268
41,510
57,290
55,000
19,491
44,960
37,753
56,220
69,000
64,252
41,819
60,542
29,687
65,500
23,570
40,490
95,121
27,879
65,333
36,700
58,000
21,081
21,307
68,991
29,687
132
125
125
12 5
12 5
4 16
125
125
125
12,5
12.5
125
12.5
24
125
132
22
132
125
13.2
125
125
24
24
13 2
24
RL
RL
RL
RL
RL
RE
1
1
1
I
I
1
1
1
1
1
1
1
I
1
E
1
1
1
1
1
1
1
I
1
1
1
057750
057750
057750
0,57750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0 57750
057750
057750
057750
057750
057750
057750
057750
101 13
98 39
186 76
182 47
14454
55.32
146.12
11735
133 95
87 60
8629
121 10
103.27
83.23
0 00
74 64
155 93
121 11
80 74
9049
85 85
135 78
44 75
4237
201 94
8323
310 15
299 83
209 99
289 82
278 24
98 60
227 45
19099
28441
349 06
325 04
211 56
30627
150 18
212 07
119 24
204 83
481 21
141 04
330.51
185 66
293 41
106 65
107 79
349 02
150 18
2
4
3
2
2
0
0
2
3
2
3
2
4
0
2
1
2
2
2
0
2
2
0
0
3
3
66
24
3 75
3 75
9,501
29,687
24
RE
1
057750
8323
150 18
3
115
67
67
67
67
115
67
67
115
67
115
115
67
69
67
115
67
115
115
69
115
125
42
12 47
42
4 16
125
42
125
132
132
13 2
132
42
42
125
132
4 16
125
125
138
12 5
5
75
10
5
75
10
5
10
15
15
15
15
5
75
3 75
15
5
15
15
10
12
5
9 375
14
5
9375
14
5
125
28
25
25
25
5.25
9 375
5
25
6.25
25
25
14
20
11,720
12.000
6,316
8,777
12,000
11,700
10,304
14,470
12,281
26,720
15,460
11,990
10,526
11,800
6,912
16,074
6,851
17,636
17,600
10,742
20,200
28,660
48,000
19,491
40,107
44,565
33,600
34,922
58,190
52,074
80,450
58,647
52,620
32,485
44,605
20,909
56,237
19,040
65,206
65,000
23,613
63,100
125
4 16
4 16
4 16
416
132
4 16
125
132
125
13.2
132
4 16
4 16
12 5
13 2
13.2
125
12.5
132
125
RL
RE
RL
RL
RL
RL
RL
RL
RL
RL
R,L
RL
RE
RE
RE
RE
8.L
1
1
1
I
I
1
I
1
E
1
1
1
1
1
I
I
1
I
1
I
E
057750
0 57750
057750
0.57750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0 57750
057750
0 57750
057750
057750
057750
057750
102 67
105 12
5532
7689
105 12
10249
90.26
126 76
0 00
234 07
135.43
105 03
9221
103 37
6055
140 81
60 01
15449
154.18
94 10
0 00
14499
242 83
9860
202 90
225.45
169 98
176 67
29438
18 44
406 99
296 69
26620
164 34
225 65
105 78
284 50
96.32
329 87
328 83
119 46
114 92
2
3
1
2
2
2
2
1
1
3
3
3
3
2
2
3
2
2
2
2
0
115
13 2
15
28
12,369
51,686
132
RL
E
057750
000
94 13
2
66
22
5
5
10,100
32,392
22
RL
1
057750
88 48
163 87
2
RE
RL
RE
RE
RE
RE
RL
RE
RL
RE
RE
RE
RL
RL
R,L
RL
RE
ILL
RL
RL
RL
RE
RL
RE
RL
R-11,
RL
RL
RE
RL
57
36
93
64
64
SCH 3- Page 117 of 490
06776
Schedule 0-6.3
Page 44 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix I
Distribution Substation
Line
No.
l
210 S HOBBS E
211 S HOBBS W
212 S LOVING
213 S PLAINVIEW
214 SAMSON
215 SAND DUNES
216 SEMINOLE INTG
217 SHAMROCK PUMP
218 SHELL C3
219 SHERMAN CO
220 SLATON
221 SLATON CITY
222 SLAUGHTER
223 SMITH
224 SONCY
225 SOUTHEAST
226 SOUTH GEORGIA EAST
227 SOUTH GEORGIA WEST
228 SOUTHLAND
229 SOUTH LOVING
230 SPEARMAN SUB EAST
XFMR
231 SPEARMAN SUB WEST
XFMR
232 SPEARMAN INTERCHANGE
233 SPRINGCREEK
234 SPRING DRAW
235 SPRINGLAKE
236 SUDAN RURAL
237 SUNSET
238 TEAGUE
239 TENNECO
240 TEXACO
241 TEXAS FARMS
242 TMC
243 TOKIO
244 TRANSPETCO
245 TUCO
246 UNITED SALT
247 URTON
248 VAN BUREN #1
249 VAN BUREN #2
250 VEGA
251 VICKERS
252 W ANTON
253 W BENDER
254 W BORGER
255 W CLOVIS 23 KV
256 W CLOVIS 13.2 KV
257 W LITTLEFIELD
258 W MULESHOE
259 W PLAINVIEW
260 WADE
261 WARD
262 WASSON
263 WATERFIELD
264 WEATHERLY
265 WELLMAN
266 WESTRIDGE
267 WHERRY HOUSING
268 WHITAKER
269 WHITE CITY
270 WHITEFACE
271 WHITEHEAD AMOCO
272 WHITHARRAL
273 WHITTEN
274 WILDORADO
275 WILLS OIL
276 WOOD DRAW
277 YANCY
278 YELLOW HOUSE
279 ZAVALLA
280 ZIA
Voltage
Low
High
Side, kV
Side, kV
2
3
Ratings
Max
Nominal
MVA
MVA
5
4
No Load Full Load
Losses
Losses
WATTS WATTS
7
6
Low
Side
Class
8
Primary
Load
Factor
11
No Load Full Load Number of Percent
Feeder
Transf.
Losses
Losses
Excluded
MWH
Circumts
MWH
14
15
12
13
Verify
Flag
R,L,E
9
Eaclude
Flag
057750
057750
057750
057750
0J7750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
12857
0 00
68 63
144 54
164 86
8322
11031
22 19
0 00
237 40
1 l4 47
69 16
60 97
69 16
218 83
161 88
185 01
19552
2766
68 63
108 76
203 75
63 44
217 99
27824
235.24
151 77
295.28
40 05
114 49
272 67
17728
123 25
112 96
123 25
478 72
255 17
28350
276.52
49 30
217 99
20677
2
2
2
3
2
3
3
0
0
3
2
2
1
2
4
2
3
3
1
3
2
10
115
115
69
67
115
67
115
66
115
115
69
67
67
67
67
115
115
115
69
69
115
13.2
12 5
132
125
13.2
125
22 86
24
4 16
34 5
229
42
24
42
13.8
132
13 8
13 8
24
13,2
4 16
12
12
112
10
12
75
16 8
1
10
12
10
3 75
3 75
3 75
20
15
15
15
15
112
73
20
20
175
14
20
84
28
1
14
12
10
3 75
42
3 75
20
25
25
25
15
175
105
14,677
18,500
7,835
16,500
18,820
9,500
12,592
2,534
12,852
27,100
13,067
7,894
6,960
7,894
24,981
18,480
21,120
22,320
3,158
7,835
12,416
40,275
57,000
43,091
55,000
46,500
30,000
58,368
7,917
31,876
53,900
35,044
24,364
22,330
24,364
94,630
50,440
56,040
54,660
9,745
43,091
40,872
12.5
125
132
125
125
125
22
24
4 16
33
22
4 16
24
4 16
13 2
132
132
13,2
24
132
4 16
RL
RL
R-L
RE
RL
R-L
ILL
RL
RE
RL
R-L
1
E
1
1
1
1
1
1
E
1
1
I
I
I
1
I
1
I
1
1
I
115
4 16
75
10 5
13,440
41,855
4 16
RL
1
057750
117 73
211 74
2
67
67
118
67
66
115
115
69
67
115
67
67
67
67
69
115
67
67
69
69
66
115
115
67
115
69
67
67
69
115
67
67
67
67
69
67
115
67
67
67
67
115
67
67
118
67
66
67
115
344
13 2
13 2
132
12.5
132
125
13,2
12.5
132
42
12 5
42
12.5
124
125
13 2
138
132
23 9
22
132
132
24
132
125
12.5
125
125
125
24
13.8
13 8
12 5
13 2
12 5
13 8
12.5
12 5
24
4 16
125
125
125
132
416
12.5
125
132
10
75
168
75
25
15
10
15
12
75
10
5
75
10
0 75
12
15
15
11.2
10
6
12
15
12
15
15
5
125
3 75
4
2
10
10
5
12
3
15
25
10
3 75
2.5
10
10
15
168
2
3 75
10
10
10
9 375
28
75
25
28
14
25
20
9,375
125
6.25
75
13.3
0 75
12
25
25
14
14
6
224
25
224
25
15
5
20
4 68
4
2
125
11.2
625
20
3 65
25
25
10
4 69
3 125
125
10
1.5
28
2
5
125
14
14,320
15,760
11,713
11,060
4,608
15,300
13,610
11,170
20,146
7,670
15,600
9,216
11,657
16,050
1,382
21,940
29,725
23,760
10,575
23,600
11,394
11,190
14,838
10,800
12,160
2,765
9,216
16,500
11,000
13,610
5,160
13,670
15,760
5,000
9,020
5,530
22,520
4,608
14.695
7,120
6,560
21,360
15,984
2,730
8,989
5,160
10,992
18,680
22,080
61,030
41,150
67,783
52,193
13,940
46,900
30,300
57,590
52,610
23,270
54,420
27,879
37,611
58,110
4,182
63,559
70,460
62,700
43,151
50,236
30,261
38,840
55,493
47,800
55,680
8,364
27,879
55,000
33,000
30,300
15,661
68,760
41,150
15,000
45,460
16,728
72,200
13,940
57,235
27,771
16503
64,570
59,797
7,800
67,373
15,536
32,937
51,100
39,216
33
13 2
13.2
132
12 5
132
125
132
12 5
132
4 16
12 5
4 16
12 5
12 5
125
13.2
132
132
22
22
132
132
22
132
125
125
125
12.5
125
24
132
132
12 5
13.2
12 5
13,2
125
12 5
24
4 16
125
13.2
12 5
132
4 16
12 5
125
12.5
RL
1
I
1
1
1
1
1
1
E
I
I
I
1
1
1
1
I
1
1
1
I
I
1
I
1
1
1
I
1
1
I
1
1
1
1
I
I
1
1
1
1
1
1
1
1
I
1
1
1
057750
0 57750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
057750
0.57750
0 57750
057750
057750
057750
057750
057750
057750
0 57750
057750
057750
0 57750
057750
057750
057750
057750
057750
0 57750
057750
057750
0 57750
057750
0 57750
057750
057750
0 57750
057750
0 57750
0.57750
057750
057750
057750
057750
057750
125 44
138 06
10261
96 89
40 37
13403
119.22
9785
0 00
67 19
13666
80 74
102 12
140 60
12 11
19219
260 39
208 14
92 64
206.74
99 82
98 02
129 98
9461
10652
2422
80 74
144 54
96 36
119 22
4520
119 75
138 06
43 80
79 02
48 44
19728
4037
128 73
62 37
57 47
187 11
140 02
23 91
78 74
45.20
9619
163 64
19342
308 74
208 17
34291
264 04
70 52
23726
15328
29134
31 94
117 72
275 30
141 04
19027
293 97
21 16
32154
35645
317 19
218 30
254 14
153 09
19649
280 73
241 81
281 68
4231
141 04
278.24
166 94
153 28
7923
347 85
208 17
75 88
229 98
8462
365.25
7032
289 54
14049
83.49
326 65
30251
3946
34083
7859
16662
25851
198 39
1
2
3
2
2
3
2
1
2
1
0
1
2
2
1
2
3
3
2
1
1
2
3
1
2
1
2
4
1
1
0
3
2
1
2
2
3
2
2
1
1
2
2
1
3
0
1
2
1
RE
RL
RE
R-L
RE
RL
RL
RL
RE
R-L
RE
RL
R,L
RE
RL
RE
RL
RL
RL
R,L
RE
R-L
R-L
RE
RL
RL
RL
RL
R-L
RE
R-L
R,1,
RL
RL
RE
RE
RE
RE
R-L
R-L
RL
RE
RE
RL
RE
RL
RE
RL
RE
RL
R-L
R-L
RE
RL
RL
RE
R-L
RE
78
29
88
SCH 3- Page 118 of 490
06777
Schedule 0-6.3
Page 45 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix I
Distribution Substation
Line
No.
1
281 ZODIAC
Volta e
Low
High
Side,kV
Side, kV
3
2
67
416
Ratings
Nominal
Max
MVA
MVA
5
4
10
112
286
287
288
19,282
64,592
No Load Full Load
Losses
Losses
MW
MW
282
283
284
285
No Load Full Load
Losses
Losses
WATTS WATTS
6
7
Total nominal ratings 2,702.780 MVA
Sum of demands at Primary and below from "H" 2,268.041 MW
54.139 MW
System at peak Hr Primary Generation
Sum of demands adjusted for Primary Generation 2,213.902 MW
289
Hours in Period
3.581
11.97
Low
Side
Class
8
4.16
Verify
Flag
R,L,E
9
Exclude
Flag
R,L
I
10
Primary
Load
Factor
11
057750
Total
Losses
MW
15.54
No Load Fall Load Number of Percent
Transf.
Feeder
Losses
Losses
Excluded
MWH
Circuits
MWH
14
15
12
13
168 91
326 76
2
No Load
Losses
MWH
Load
Losses
MWH
Total
Losses
MWH
30,107
60,542
90,649
8760
290 Summary Information
291 KV Level
I
292 Total Nominal MVA by Voltage
293 Load by Voltage
294 Load on transformers without
feeders
295 Total Feeders
296 Feeders excluding partial
feeders
297 Load on Feeders
4.16 I
21848
2.4
I Total I
87 60 2,702 78
821 41
9 44
178 96
68 60
71 76 2.21390
27 99
146 98
197 00
192.67
211 00
201.91
46 00
46.00
861.15
811.97
110.36
13.2
I 12.5 I
1,101.30 1,002 80
33
I
108 90
22
I
183 70
8920
0 00
150 47
0 00
902 10
40 95
17 00
16.34
3600
36.00
89.20
150.47
29 00
29.00
536 00
521.92
43.77 2,066.92
MVA
MW Load
MW Load at the trensformer
Number of Feeders
All feeders less % of transformer not included
MW Load on feeders
SCH 3- Page 119 of 490
06778
Schedule 0-6.3
Page 46 of 55
Sponsor: Luth
Docket No. 45524
ow c, a,
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SCH 3 - Page 120 of 490
06779
Schedule 0-6.3
Page 47 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix K
Distribution Line Transformer Loss
Demand Losses
Line
No.
1
2
3
Commercial customers may come only offthe transformer or larger service drops,
Adjusted Meters
331,250
93,753 trans
293,839 meters
Residential
4
Commercial
76,282
5
3 Ph Commercial
38,871 meters
6
:esidential and Small Commercial
1,084,021 KW
4,102,239,817 KWH
(Level 6)
7
Commercial Load
664,745 KW
3,447,301,207 KWH
(Level 5)
8
Total Load
1,748,766 KW
7,549,541,024 KWH
9
38,871
meters
Load/Residential Customer
10 Load/Commercial Customer
42,807 trans
Typical Transformer Losses
13
Residential Transformer Losses(Watts)
Load/transformer
11 56 KW
17 10 KW
Load/transformer
15 53 KW
323
892
Residential
7,12523
Commercial
8,861 05
17 Load Losses(KW)
17,835.35
13,414 54
18 Total Losses(KW)
24,960.58
22,275 59
FL watts
FL watts
25
KVA Transformer
100
KVA Transformer
47,236.17
19 Total Line Transformer Losses (KW)
Energy Losses
20
Total Sales
22 Load Factor - Based on Total Secondary
7,549,541,024 KWH
0 4928
Demand and Energy Above
24 Loss Factor
25
mtr/trans
313.37
15
16 No Load Losses(KW)
23
0 90805
190.24
14 Commercial Transformer Losses(Watts)
21
mtr/trans
3.27 KW
76 NL watts
207 NL watts
11
12
3 53322
Total Dist. Line Transformer Losses
0 3179
131,524 MWH
SCH 3 - Page 121 of 490
06780
Schedule 0-6.3
Page 48 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix L
Secondary and Service Loss
Line
No.
1
Secondary Demand Losses
2
3
4
5
Demand Served at Secondary Level
Level 5 - Sec Distribution Transformers
Level 6 - Sec Distribution Lines
Total Demand
6
7
8
9
Energy Served at Secondary Level
Level 5 - Sec. Distribution Transformers
Level 6 - Sec Distribution Lines
Total Energy
10
Secondary Conductor - 60' of 1/0 Conductor
11
Resistance
12
Load /Residential Customer
3 27 KW (From Appendix K)
13
Load /Commercial Customer
17 10 KW (From Appendix K)
14
Losses for Secondary Run
13 64 amps
15
16
Number of Residential Customers Served at Secondary
Assumes that one meter was served at transformei
664,745 KW
1,084,021 KW
1,748,766 KW
3,447,301,207 KWH
4,102,239,817 KWH
7,549,541,024 KWH
0 013 ohms
4.72 watts loss
237,497 Customers
1,122 KW
Total Secondary Loss
17
Service Demand Loss
18
19
Resistance Values
20
21
Residential Service
65' of #2 Triplex
0.02028
ohms
22
23
Commercial Service
30'of#I/O Quad
0 00636
ohms
24
Residential
331,250
meters
13 64 amps/mtr
25
Commercial
38,871
meters
4114 amps/mtr
26
Residential Loss/Meter
7 54
watts
2,498 KW
27
Commercial Loss/Meter
32 29
watts
1,255 KW
3,753 KW
Total Service Losses
28
Secondary and Service Energy Losses
29
7,549,541,024 KWH
30
Total Sales
31
32
33
Load Factor - Based on Total Secondary
Demand and Energy Above
Loss Factor
0 4928
34
Total Secondary and Service Demand Loss
4,875 KW
35
Total Secondary and Service Energy Loss
13,574 MWH
03179
SCH 3 - Page 122 of 490
06781
Schedule 0-6.3
Page 49 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix M
Loss Summary
Summary of Loss Evaluation
12 Months Ended June 30, 2013
PerrPnt nf Tnta1 i.nccrc
Line
No.
1
2
3
4
5
System Component
Transmission Lines
345 kV
230kV
115 kV
69 kV
Demand
MW
Energy
MWH
Adjusted
Energy
MWH
Demand
Percent
Energy
Percent
Factored KWH
7.81
40.28
85.22
25.16
38,707
293,567
344,234
93,689
38,389
291,157
341,409
92,920
1.79
9.21
19.48
5.75
2.11
15.98
18.74
5.10
38,389,231
291,157,173
341,408,804
92,919,805
6 Corona and Insulator Loss
7
345 kV
230 kV
8
9
115 kV
10
69 kV
1.46
2.05
1.19
0.31
12,787
17,986
10,426
2,753
12,682
17,839
10,340
2,731
0.33
0.47
0.27
0.07
0 70
0 98
0 57
0 15
12,681,918
17,838,623
10,340,292
2,730,769
11 Autotransformers - Load
12
345/230kV
230/115 kV
13
14
115/69 kV
0.67
9.00
5.90
6,193
47,573
28,024
6,143
47,182
27,794
0.15
2.06
1.35
0.34
2.59
1.53
6,142,577
47,182,174
27,793,894
15 Autotransformers - No Load
345/230 kV
16
230/115 kV
17
115/69 kV
18
0.43
2.92
1.58
3,019
25,595
14,919
2,994
25,385
14,797
0.10
0.67
0.36
0.16
1.39
0.81
2,994,344
25,385,113
14,796,653
15 54
90,649
89,905
3.55
4.93
89,905,104
185 75
47.24
4 87
661,778
131,524
13,574
656,346
130,444
13,462
42.47
10.80
1.11
36.02
7.16
0.74
656,346,172
130,444,111
13,462,156
437.40
1,836,997
(15,079)
1,821,919
19 Distribution Sub Transformers
20 Distribution
Primary
21
Line Transformers
22
Secondary & Services
23
24 Total Determined Losses
25 Undeterminable Losses
26 Total Losses
1,821,919
1,821,918,912
SCH 3 - Page 123 of 490
06782
Schedule 0-6.3
Page 50 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix N
Powertlow Study Loss Results
CASK T7AME: 2422KWGB2EIPd:4L-12S,_ SU-194ER F?EA1R_sffiv
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--------------- TPAAkEM1E,^sIC3S3 1.'"WE LOSSES ( MW) ----------------------t
345 ktr
7.808521
I
t
230 xV9 t 115 kV } ( 69kv p (
85.22776
25.16303
40.27761
.._>-_i>a -a_,>......... ...-..,-_.,....,__' CASE TOTALS
Tc2'^.r.=.; . '- -)S!7rS :
T-:•Ti.:.
T,Tr:^ 23u_V
TC^Li^^ 7.7 5k1^
TOT,k:.,
59xV
"s 74 . G42SMCd
LINESLINES:
Y,T,NES:
LIN$$:
f
74
340
293
TOTAL 3'7^/ : ?3i3kV T^i.AIn5£DRt,1:^R8:
S
Tf,ll,':L 315/375k1Y0
TOTAL 230/115 t 13b3 KV T+^.kiid 3F'CSR^a!at^s:
45
TOT33B..
'.v/63:tV TiLqN^FQRM^R3:
0
TOTAL 11^/69kV
79
SCH 3 - Page 124 of 490
06783
Schedule 0-6.3
Page 51 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix N
Powerflow Study Loss Results
CASE NAME: 2012MDWG82FINAL-12S_4669.sav
TITLE LINE 1: t§DWG 2012 $2 FINAL WITH 2011 MEWS
TITLE LINE 2: NDWG 2012S WITS %#MWG 2012S [4669.2 - SEGMENT 11
BUS RANGE: 522800 -- 528799
* * • * * * * * * x LOSSES B X ELEMENT C L A S S *****#****
------------------------------ TRANSFORMER LOSSES (M54) ----------------------------345/230 kV 1[ 345/115 kV I[ 230/115 kV }[ 230/69 kV l t 115/69 kV I[
TOTAL
0.605217
6,538837
0.0
0.0
4.086288
11.23034
1
MIDLAND & BORDEN 230/138)tY LOSSES IN 230/115kV LOSSES ABOVE: [(3.4766945, 0.0942993 l
----•------------------ TRANSMISSION LINE LOSSES (MW) --------------- -----[
345 kV
4.340492
j[
230 kV
27.63203
t[
115 kV 1[ 69 kV
49.59095
15.6057'2
If
TOTAL 1
97,1491.9
------------------------ CASE TOTALS
TOTAL LOSSES:
108.37951,YW
TOTAL 345kV LINES:
TOTAL 230kV LINES:
TOTAT, 1157tV LINES:
TOTAL 69kV LINES:
6
70
340
293
TOTAL 345/230kV
TOTAL 345/115kV
TOTAL 230/115(138)kV
TOTA:, 230/69kv
TOTAL 11 5/69kV
TRANSFORMERS:
TRANSFORMERS:
TRA.NSFORMERS.
TRANSFORMERS:
TRANSFORMERS:
5
0
45
0
79
CASE Iv.AME: 2012MD6r'GB2FSNAL-12S...3436. sav
TITLE LINE 1: KONG 2012 B2 FINAL WITH 2011 MMWG
TITLE LINE 2: M?Y7G 2012S WITH 8S~IG4G 20125 [3436.9
BUS RANGE:
SEGMENT 27
522800 -- 528799
* * * * ' * * * * * L O S S E S B Y E L E M E N T C L A S S x**^'**** x*
----------------------------- TRANSFORMER LOSSES {_} ------------------------------[ 345/230 kV
0.69762
345/115 kV IC 230/115 kV 1[ 230/69 kV I( 115/r,9 kV I j TOTAL
0.0
5.179602
2.958_OS
0.0
8.835327
j
MIDLAND & BORDEN 230/138kV LOSSES IN 230I115kV LOSSES ABOVE: [ O.G4$$11, 0.0661545 J
----- --------------- TRANSMISSION LINE LOSSES
j
(Y4W)
---------------------
345 kV 1[ 230 kV ][ 115 kV j[ 69 kV
3.465938
33.41922
33.87829
9.379807
It
TOTAL
80.14325
j
CASE TOTALS
TOTAL LOSSES:
TOTAL
TOTAL
TOTAL
TOTAL
88.97858MW
345kV LINES: 6
230kV LINES:
70
115kV LINES: 340
69aFV LINES: 293
TOTAL 345/230kV T12A:'+tSFORMEs'tS:
TOTAL 345/125kV TRANSFORMERS:
TOTAL 230/115(138)kV TRANS€ORP2ERSx
TOTAZ. 230/69kV TRANSFORMERS:
TOTAL 115I69kV TRANSFORMERS:
$
0
45
0
79
SCH 3 - Page 125 of 490
06784
Schedule 0-6.3
Page 52 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix N
Powerflow Study Loss Results
CASE NAME* 2013MDv, -F
.-'1. Tt,h k 5i 1 1 1. 2 2
TITLE ,LINE
_ a(:
i Ne:l'>
TITLE LINE sc tA_r- 2013u vtITH .2fi•;G 20-13G %3572_4 -`;1['R.Fr;7 _
BUS RANGE-
52_E3'0 -- 52873?
x * * * x * tr s v . ^
-----.....-,.
L U 5 : S E S a"§ Y
E L EM E N T CLASS
_ "°__._.--------,---- TRANSFORMER LOSSES fiNWI
-*1 ** ++t ,t
-------------
-^._-----__ ---
345/230 kV IC 398/115 kV J I 230 3 115 kV l[ 230169 W 1{ 115169 kV 1 l TOTAL I
0.66189
5.030091
0.0
0.0
2.945627
5.633508
MIDLAND & BORDEN 230{133kLJ LOSSES IN 230/115kV LOSSES ABOVE:
-------------------- TRANSMISSION LINE LOSSES (MW)
f
395 kV J
2,418605
230 k.V
35.85329
G 0.0649834, 0,108;19 1
----------- ---------
115 kV J1
69 kV
40.298.55
9,070039
Tow-f,
SI.a9uE11
I
------------------------ CASE TOTALS
TOTAL
96.229IS14W
34SkV LINES:v`
-1L I jC3kVLINES:
7?
.)_t°.L I:SY..V 1:,774ES:
350
693.i'
-0 -AI,
231
TOTAL 345/230kV TF.A;S^4)Rt.IERS:
-:'07'.:, .345i"115kV
TO- Al, 2 30/69kV a.P-
:"O!^.ME4^;
Tv AL `,15168kSI
6
0
400
77
CASE NAME; 2013MDWG..EStYA?,.,..23G_.4014.sav
TTT!,E I,7NR 1. MDP:C; 2O?"3 :ItdAL
MIT"
!'
W^$G
TST_L LZFL 2: MJWG 2073G i;+=ti
BUS ia7.KGE:
t40119.25 -Ss^erEPIT 41
522800 -- 520799
* + * * x * * x x .
$ E N
N TI C L A S S
LO SSES B Y E E L E FM
-----------------------------T'i21+?FSPO!"tt&^.R LOSSES (MW)
3,15/2-,0 kV l
0.83cC8£+
* s^+ a x^^ x{
°-_-°°---_..a..._--,,.-..,...»..,->ns®----------------
TOTAL
3451115 kV j'{ .`L30:71, F:',' 1 I 230/59 kV1€ 115/69 kV j;
i^.,(â
3.28249
9,6$4475
" .»?S9
0.0
0.1216-15 i
1=_c r1U &3{)RDliU 230I136kV LOSSES its 73:if115kw7 LOSSES AS{>Vt:: [
- . ......,».........»..,»...... __
TeT I^7 ^ . + T LINE LOSSES {W)
- --- --- -- -- -- ------ --
3- -^[ 23C kv I ( 115 kV 7[ G-° kV 1 €
17 . i9t>:^<
44.14527
37,a5057
e -_r_-- - ^:ra
---- - -._,
TC+TAL LOs^r.s:
TOTAL
102.34C :,
l
LTALS
111,9839MW
TaTR^L 30cV 7-1TiiF'3:
6
TnT1'.I.
72
a.s^t.r
l
LINES!
.L 115kV t,7Ivi.8:
63k t_,I7 t_: :
i
350
291
OCTAL 3-35/230kV TFv£d^F ;".-.RS:
6
'}45/15A:v '7xAvsPC^-,^-4ER.3:
0
TOTAL
TCk'rFi.
4$
0
TOTAL 115J6^A:V
SCH 3 - Page 126 of 490
06785
Schedule 0-6.3
Page 53 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3 - Page 127 of 490
06786
Schedule 0-6.3
Page 54 of 55
Sponsor: Luth
Docket No. 45524
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SCH 3 - Page 128 of 490
06787
Schedule 0-6.3
Page 55 of 55
Sponsor: Luth
Docket No. 45524
Southwestern Public Service Company
System Line Loss Calculation
Appendix Q
Demand and Energy Factors
12 Months Ended June 30, 2013
Rate Class Loss Factors by Loss Level
Line
No.
I
Residential Lighting
2
3
4
5
6
7
Residential Space Heating
Small General Service
General Service - Secondary
General Service - Primary
Large General Service
Transmission Backbone
8
9
10
11
12
13
14
15
16
17
Demand Loss Factors
Energy Loss Factors
6
6
6
5
4
1.161975
1.161975
1.161975
1.161975
1.127359
1.120217
1.120217
1.120217
1.120217
1.099263
2
3
1.026174
1.035392
1.025158
1.032914
6
1.161975
1.120217
6
1.161975
1.120217
6
1.161975
1.120217
6
4
5
4
2
3
1.161975
1.127359
1.161975
1.127359
1.026174
1.035392
1.120217
1.099263
1.120217
1.099263
1.025158
1.032914
Loss Level
Sub-Transmission
Street Lighting
Area Lighting
Small Municipal and School
Large Municipal
Large Municipal - Primary
Large Schools
Interruptible Service -SAS 4
Wholesale - Service -115 kV
Wholesale - Service -69 kV
* For Levels 5 & 6, the Composite Factors used in billing applications are stated.
SCH 3 - Page 129 of 490
06788
Schedule 0-7.1
Page 1 of 14
Sponsor: Marks
Docket No. 45524
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06789
Schedule 0-7.1
Page 2 of 14
Sponsor: Marks
Docket No. 45524
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SCH 3 - Page 131 of 490
06790